Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
26.12.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7222/1-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7222/1-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Press release
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7222/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D st 1002t10 psdm. Crossline 2440. Inline 1851
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Eni Norge AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    1629-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    50
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    14.06.2016
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    02.08.2016
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    01.01.2018
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    20.02.2018
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    DRY
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    34.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    424.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2400.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    2400.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.5
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    PERMIAN
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    RØYE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 56' 45.94'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    22° 19' 26.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8100659.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    347066.29
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    7987

  • Wellbore history
    Wellbore history
    General
    Well 7222/1-1 was drilled to test the Aurelia prospect on the northern part of the Loppa High in the Barents Sea. The objective was to prove hydrocarbons in the Triassic Snadd and Kobbe formations, and to test the prospectivity of the Early Permian Ørn Formation.
    Operations and results
    Wildcat well 7222/1-1 was spudded with the semi-submersible installation Scarabeo 8 on 14 June 2016. During coring at 1479.5 m, the string stalled and mud losses at 45 m3/hr occurred, resulting in a very short core and time spent on curing the mud losses. TD was set at 2400 m in the Late Permian Røye Formation, which was earlier than planned, due to slow drilling and several bit trips in massive chert. The well was drilled with seawater and hi-vis sweeps down to 737 m and with EMS-400 oil based mud from 737 m to TD.
    The Carnian age reservoir in the Snadd Formation was penetrated at 1015m, and found to be water bearing. The sequence had a gross thickness of 115 m, and a net sand of 44.3 m, giving a net to gross value of 38.6%. Porosity of 22% was calculated for this reservoir zone, with dry gas shows observed. The Ladinian age Snadd reservoir was penetrated at 1181 m, and found to be water bearing. The reservoir zone had a gross thickness of 24.6 m, net sand of 15.5 m giving a net-to-gross value of 63.1%. Porosity of 18% was calculated, and as with the Snadd reservoir, dry gas shows were observed. Top Kobbe Formation reservoir was penetrated at 1464 m. The reservoir sandstone had a thickness of 33 m, and was found to be tight and water bearing. Calculated porosity was 12.5%, with very low permeability, as confirmed from the recovered core. The Steinkobbe Formation, an important Triassic age source rock for oil and gas in the Barents Sea, was penetrated in this well, from 1693 to 1969 m. The Late Permian Røye Formation was found to consist of tight, water-bearing carbonates.
    Weak oil shows and wet gas were described on sandstone cuttings from the interval 1478 to 1522 m in the upper part of the Kobbe Formation.
    One short core was cut from 1478 to 1479.53 m in the upper part of the Kobbe Formation. No fluid sample was taken.
    The well was permanently abandoned on 2 August 2016 as a dry well.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    740.00
    2399.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    1478.0
    1479.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    1.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    458
    539
    539
    1464
    1464
    1693
    1969
    2075
    2195
    2195

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HNGS XPT NGI
    1107
    1550
    MWD - DIR
    458
    514
    MWD - DIR GR RES
    514
    737
    MWD - DIR GR RES SON
    737
    1015
    MWD - DUMB IRON
    1479
    1542
    MWD - DUMB IRON
    1556
    1556
    MWD - GR RES CAL DEN NEU
    2125
    2125
    MWD - GR RES DEN NEU SON
    2338
    2400
    MWD - GR RES DEN NEU SON STETH
    2125
    2338
    MWD - GR RES DIR SON
    1015
    1479
    MWD - GR RES DIR SON ECD
    1479
    1556
    MWD - GR RES DIR SON ECD LWD
    1677
    2125
    MWD - GR RES SON STETH PRES
    1556
    1556
    MWD - IRON DUMB
    1556
    1677
    USIT CBL PPC GR LEH ECRD
    434
    2123
    VSP GR LEH ECRD
    515
    2390
    XPT GR LEH ECRD
    2249
    2320

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    36
    505.6
    42
    511.0
    0.00
    SURF.COND.
    20
    732.2
    24
    738.0
    0.00
    740.0
    740.0
    1.39
    LOT
    PILOT HOLE
    740.0
    8 1/2
    740.0
    0.00
    INTERM.
    13 3/8
    1007.8
    16
    1015.0
    0.00
    1018.0
    1018.0
    1.88
    LOT
    LINER
    9 5/8
    2124.0
    12 1/4
    2125.0
    0.00
    2128.0
    2128.0
    1.24
    FIT
    OPEN HOLE
    2400.0
    8 1/2
    2400.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    458
    1.03
    1.0
    --
    741
    1.14
    13.0
    OB
    907
    1.10
    12.0
    OB
    1015
    1.20
    16.0
    OB
    1388
    1.30
    21.0
    OB
    1542
    1.22
    13.0
    OB
    1615
    1.14
    14.0
    OB
    2095
    1.10
    14.0
    OB
    2104
    1.14
    15.0
    OB
    2277
    1.10
    14.0
    OB
    2400
    1.10
    12.0
    OB